WO2013152099A1 - Expandable reamers and methods of using expandable reamers - Google Patents
Expandable reamers and methods of using expandable reamers Download PDFInfo
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- WO2013152099A1 WO2013152099A1 PCT/US2013/035112 US2013035112W WO2013152099A1 WO 2013152099 A1 WO2013152099 A1 WO 2013152099A1 US 2013035112 W US2013035112 W US 2013035112W WO 2013152099 A1 WO2013152099 A1 WO 2013152099A1
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- Prior art keywords
- sleeve
- travel
- trigger
- obstruction
- housing
- Prior art date
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- 238000000034 method Methods 0.000 title claims description 13
- 239000012530 fluid Substances 0.000 claims description 75
- 238000005553 drilling Methods 0.000 claims description 73
- 238000007789 sealing Methods 0.000 claims description 26
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- 230000003247 decreasing effect Effects 0.000 claims description 3
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- 241000282472 Canis lupus familiaris Species 0.000 description 6
- 239000007789 gas Substances 0.000 description 4
- 239000003381 stabilizer Substances 0.000 description 4
- 239000007787 solid Substances 0.000 description 3
- 230000008901 benefit Effects 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 230000009467 reduction Effects 0.000 description 2
- 238000007792 addition Methods 0.000 description 1
- 230000005540 biological transmission Effects 0.000 description 1
- 230000000903 blocking effect Effects 0.000 description 1
- 238000005520 cutting process Methods 0.000 description 1
- 230000037430 deletion Effects 0.000 description 1
- 238000012217 deletion Methods 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
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- 230000000717 retained effect Effects 0.000 description 1
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- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B10/00—Drill bits
- E21B10/26—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers
- E21B10/32—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
- E21B10/322—Drill bits with leading portion, i.e. drill bits with a pilot cutter; Drill bits for enlarging the borehole, e.g. reamers with expansible cutting tools cutter shifted by fluid pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
- E21B7/28—Enlarging drilled holes, e.g. by counterboring
Definitions
- the disclosure relates generally to expandable reamers for use in boreholes in subterranean formations and methods of using such expandable reamers. More specifically, disclosed embodiments relate to expandable reamers that selectively extend and retract blades.
- Expandable reamers are generally employed for enlarging boreholes in subterranean formations, in drilling oil, gas, and geothermal wells, casing is usually installed and cemented to prevent the walls of the borehole from caving in while providing requisite shoring for subsequent drilling to greater depths. Casing is also installed to isolate different formations, to prevent cross flow of formation fluids, and to enable control of formation fluids and pressure as the borehole is drilled. To increase the depth of a previously drilled borehole, new casing is laid within and extended below the original casing. The diameter of any subsequent sections of the well may be reduced because the drill bit and any further casing must pass through the original casing. Such reductions in the borehole diameter may limit the production flow rate of oil and gas through the borehole. Accordingly, a borehole may be enlarged in diameter when installing additional casing to enable better production flow rates of hydrocarbons through the borehole.
- One approach used to enlarge a borehole involves employing an extended bottom-hole assembly with a pilot drill bit at the end and a reamer assembly some disiance above the pilot drill bit.
- This arrangement permits the use of any standard rotary drill bit type (e.g., a rolling cone bit or a fixed cutter bit), as the pilot bit and the extended nature of the assembly permit greater flexibility when passing through tight spots in the borehole as well as the ability to stabilize the pilot drill bit so that the pilot drill bit and the following reamer will traverse the path intended for the borehole.
- This aspect of an extended bottom-hole assembly is particularly significant in directional drilling. Expandable reamers are disclosed in, for example, U.S. Patent No. 7,900,717 issued March 8, 201 1 , to Radford et ah; U.S. Patent No. 8,028,767 issued October 4, 201 1, to Radford et a!.; and U.S. Patent Application Pub.
- expandable reamers for use in boreholes in subterranean formations comprise a housing defining an internal bore. At least one blade is supported by the housing. The at least one blade is movable between an extended position and a retracted position.
- a travel sleeve is located within the internal bore and detachabiy connected to the housing. The travel sleeve defines an internal flow path and comprises a first obstruction engagement, at least one first port at a first longitudinal position, and at least one second port at a second, upper longitudinal position. The travel sleeve is located in a first sleeve position when connected to the housing and is movable from the first sleeve position to a second, different sleeve position when disconnected from the housing.
- a trigger sleeve is located within the internal flow path and detachabiy connected to the travel sleeve.
- the trigger sleeve defines an internal flow bore and comprises a sidewall, a second obstruction engagement, and at least one trigger port.
- the trigger sleeve is located in an unobstructed position when connected to the travel sleeve and is movable from the unobstructed position to an obstructed position when disconnected from the travel sleeve.
- the at least one trigger port is at least substantially aligned with the at least one second port when the trigger sleeve is in the unobstructed position and the sidewall obstructs the at least one second port when the trigger sleeve is in the obstructed position.
- the at least one blade is in the retracted position when the travel sleeve is in the first sleeve position and the trigger sleeve is in the unobstructed position.
- the at least one blade is movable to the extended position when the travel sleeve is in the second sleeve position and the trigger sleeve is in the unobstructed position.
- the at least one blade is in the retracted position when the travel sleeve is in the second sleeve position and the trigger sleeve is in the obstructed position.
- methods of using expandable reamers in boreholes comprise flowing a drilling fluid through an internal bore defined by a housing, through an interna!
- a first obstruction is released into the internal bore to engage with a first obstruction engagement of the travel sleeve.
- the travel sleeve is disconnected from the housing and the travel sleeve is allowed to move from a first sleeve position to a second, lower sleeve position when the first obstruction is engaged with the first obstruction engagement.
- At least one blade supported by the housing is extended from a retracted position to an extended position in response to movement of the travel sleeve from the first sleeve position to the second sleeve position.
- a second obstruction is released into the internal bore to engage with a second obstruction engagement of the trigger sleeve.
- the trigger sleeve is disconnected from the travel sleeve and the trigger sleeve is allowed to move from an unobstructed position wherein at ieast one trigger port of the trigger sleeve is at least substantiaily aligned with at least one second port of the travel sleeve to an obstructed position wherein a sidewal! of the trigger sleeve obstructs the at least one second port.
- Flow of the drilling fluid is redirected from the at least one second port through the internal flow path.
- the at least one blade is allowed to retract from the extended position to the retracted position in response to the redirected flow of the drilling fluid.
- FIG, 1 is a perspective view of an expandable reamer
- FIG. 2 is a cross-sectional view of the expandable reamer of FIG. 1 in a first operational state
- FIG. 3 is a cross-sectional view of the expandable reamer of FIG. 1 in a second operational state
- FIG. 4 is a cross-sectional view of the expandable reamer of FIG. 3 in a third operational state.
- Disclosed embodiments relate generally to apparatuses expandable reamers, which selectively extend and retract blades. More specifically, disclosed are expandable reamers, which, for example, may be locked in a retracted position during placement into a borehole, may be selectively actuated between an extended position and a retracted position during drilling, and may be selectively returned to the retracted position during removal from the borehole.
- the terms “upper,” “lower,” “below,” and “above” indicate relative positions of an earth-boring tool when positioned for normal use in a vertical borehole, and are not intended to limit the use of such an earth-boring tool to vertical or near-vertical drilling applications.
- drilling fluid means and includes any fluid that is directed down a drill string during drilling of a subterranean formation.
- drilling fluids include liquids, gases, combinations of liquids and gases, fluids with solids in suspension with the fluids, oil-based fluids, water-based fluids, air-based fluids, and muds.
- the expandable reamer 100 includes a housing 102 comprising a generally cylindrical structure defining an internal bore 104 through which drilling fluid may flow and having a longitudinal axis L (e.g., a central axis within the internal bore 104).
- the housing 102 may be configured to connect to other sections of a drill string.
- an upper end 106 of the housing 102 may comprise a first connector 108 (e.g., a box connection) and a lower end 110 of the housing may comprise a second connector 1 12 (e.g., a pin connection), each of which may be connected to other components in the drill string, such as, for example, sections of drill pipe, sections of casing, sections of liner, stabilizers, downhole motors, pilot drill bits, drill collars, etc.
- the housing 102 may support at least one blade 1 14, to which cutting elements may be secured, configured to engage with and remove material from a wall of a borehole.
- Each blade 1 14 may be movable between a retracted position, as shown in FIGS. 1, 2, and 4, in which each blade 1 14 is positioned not to engage with the wall of the borehole (though some incidental contact may occur) and an extended position, as shown in FIG. 3, in which each blade 1 14 is positioned to engage with the wall of the borehole.
- the expandable reamer 100 may optionally include stabilizers 1 16 extending radially outwardly from the housing 102. Such stabilizers 1 16 may center the expandable reamer 100 in the borehole while tripping into position through a casing or iiner string and while reaming the borehole by contacting and sliding against the wall of the borehole. In other embodiments, the expandable reamer 100 may Sack such stabilizers 1 16.
- a cross-sectional view of the expandable reamer 100 of FIG. 1 is shown in a first operational state (e.g., a first mode of operation).
- a first operational state may correspond to a pre-actuation, initial, retracted state, and may reflect a state of the expandable reamer 100 when tripping into a borehole.
- the expandable reamer 100 may comprise an actuation mechanism configured to selectively position the blades 1 14 in their retracted and extended positions.
- the actuation mechanism may include a travel sleeve ⁇ 8 located within the internal bore 104 and detachably connected to the housing 102.
- the travel sleeve 1 18 may be connected to the housing using detachable hardware 120A, which may comprise, for example, shear screws, shear pins, exploding bolts, or locking dogs.
- the travel sleeve 1 18 may comprise a generally cylindrical structure defining an internal flow path 122 through which drilling fluid may flow and may comprise a first obstruction engagement 124,
- the first obstruction engagement 124 may comprise, for example, a bail seat, a ba!!
- the travel sleeve 1 18 may comprise at least one first port 126 at a first longitudinal position LP t through which drilling fluid may flow from the internal flow path 122 to the internal bore 104 or vice versa.
- the travel sleeve 118 may include multiple first ports 126 proximate a lower end 128 of the travel sleeve 1 18.
- the travel sleeve 1 18 may comprise at least one second port 130 at a second, different longitudinal position LPj through which drilling fluid may flow from the internal flow path 122 to the internal bore 104 or vice versa.
- the travel sleeve 1 18 may include multiple second ports 130 located at a second, upper longitudinal position LP?, as compared to a first, lower longitudinal position LP] of the first ports 126.
- the travel sleeve 1 18 may be configured to move relative to the housing 102 when disconnected from the housing 102.
- the travel sleeve 1 18 may be in a first sleeve position when connected to the housing 102, as shown in FIG. 2, in the first operational state.
- the travel sleeve 118 may move to a second, different sleeve position when disconnected from the housing 102, as shown in FIGS, 3 and 4, in subsequent states of the expandable reamer 100.
- the expandable reamer 100 may include at least one sealing member 132 interposed between the housing 102 and the travel sleeve 1 18 to form a seal 134 between the housing 102 and the travel sleeve 1 18.
- a plurality of sealing members 132 may be interposed between the housing 102 and the travel sleeve 1 38 proximate the lower end 128 of the travel sleeve 118, forming a seal 134 between the housing 302 and the travel sleeve 1 18.
- the sealing members 132 may comprise, for example, o-rings, omni-directional sealing rings (i.e., sealing rings that prevent flow from one side of the sealing rings to the other side of the sealing rings regardless of flow direction), unidirectional sealing rings (i.e., sealing rings that prevent flow from one side of the sealing ring to the other side of the sealing ring in only one flow direction), V-paeking, and other members for forming seals between components of expandable reamers 100 known in the art.
- the sealing members 132 may comprise D-seal elements, which may comprise flexible and compressible tabular members having "D" shaped cross- sections extending circumferentially to form annular members.
- both the first and second ports 126 and 130 may be located on a common first side (e.g., an upper side) of the sealing members 132,
- the actuation mechanism of the expandable reamer 100 may comprise a trigger sleeve 136 located within the internal flow path 122 and detachably connected to the travel sleeve 1 18.
- the trigger sleeve 136 may be connected to the travel sleeve by detachable hardware 120B, which may comprise, for example, shear screws, shear pins, exploding bolts, or locking dogs.
- the trigger sleeve 136 may comprise a generally cylindrical structure including a sidewall 138 defining an internal flow bore ⁇ 40 through which drilling fluid may flow.
- the trigger sleeve 136 may comprise at least one trigger port 142 extending through the sidewall 138 through which drilling fluid may flow from the internal flow bore 140 to the internal bore 104 and the internal flow path 122 and vice versa.
- the trigger sleeve 136 may comprise multiple trigger ports 142.
- the trigger ports 142 may be at least substantially aligned with the second ports 130 of the travel sleeve 1 18 when the trigger sleeve 136 is connected to the travel sleeve 1 18.
- the trigger sleeve 136 may comprise a second obstruction engagement 144, which may comprise, for example, a ball seat, a bail trap, a solid seat, an expandable seat, or other obstruction engagements known in the art, at a lower end 146 of the trigger sleeve and may be configured to engage with a second obstruction 158 (see FIG.
- a second inner diameter ID 2 of the second obstruction engagement 144 may be greater than a first inner diameter IDs of the first obstruction engagement 124, which may enable relatively smaller obstructions to pass through the second obstruction engagement 44 to engage with the first obstruction engagement 124,
- the trigger sleeve 136 may be configured to move relative to the travel sleeve 1 18 when disconnected from the travel sleeve 1 18. For example, the trigger sleeve 136 may be in an unobstructed position when connected to the travel sleeve, as shown in FIGS.
- the trigger sleeve 136 may not obstruct (e.g., may not significantly impede) drilling fluid flow through the second ports 130 of the travel sleeve 118 because of the at least substantial alignment between the trigger ports 142 and the second ports 130.
- the trigger sleeve 136 may move to an obstructed position when disconnected from the travel sleeve 1 18, as shown in FIG. 3, in which the sidewall 138 of the trigger sleeve 136 may obstruct (e.g., may significantly impede or prevent) drilling fluid flow through the second ports 130 of the travel sleeve 1 18.
- the blades 1 14 of the expandable reamer 100 are in the retracted position regardless of pressure of the drilling fluid within the expandable reamer 100.
- locking dogs 150 that may be held in place by the travel sleeve 1 18 may lock the blades 1 14 in the retracted position.
- Such locking of the blades 1 34 may retain the blades 1 14 in the retracted position regardless of pressure exerted by drilling fluid against any component of the actuation mechanism.
- the pressure exerted by the drilling fluid may be increased or decreased without causing the blades 114 to move from the retracted position to the extended position.
- the travel sleeve 1 18 may be in the first, upper sleeve position in the first operational state.
- the detachable hardware 120A may retain the travel sleeve 118 in the first, upper sleeve position.
- the trigger sleeve 136 may be in the unobstructed position in the first operational state.
- the detachable hardware 120B may retain the trigger sleeve 136 in the unobstructed position.
- Drilling fluid may flow from the upper end 106 of the housing 102 to the lower end 1 0 of the housing 102 through the internal bore 104 of the housing 102, the internal flow path 122 of the travel sleeve 1 18, the internal flow bore 140 of the trigger sleeve 136, the first, second, and trigger ports 126, 130, and 142.
- the drilling fluid may then flow to other, Sower components in the drill string, such as, for example, a downhole motor, a drill collar, and a pilot bit.
- the blades 114 may be in the retracted position, the travel sleeve 1 18 may be in the first sleeve position, and the trigger sleeve 136 may be in the unobstructed position when the expandable reamer 100 is in the first operational state.
- a cross-sectional view of the expandable reamer 100 of FIG, 1 is shown in a second operational state (e.g., a second mode of operation).
- a second operational state may correspond to an actuated, subsequent, extendable state, and may reflect a state of the expandable reamer 100 when drilling the borehole.
- the actuation mechanism of the expandable reamer 100 may be actuated to selectively position the blades 1 14 in their extended positions.
- a first obstruction 152 may be released into the internal bore 04 to engage with the first obstruction engagement 124 of the travel sleeve 118.
- the first obstruction 152 may comprise, for example, a ball, a sphere, an ovoid, or other three-dimensional shape that may be released into the internal bore 104 to engage with the first obstruction engagement 124 and at least partially impede flow of drilling fluid out the lower end 128 of the travel sleeve 1 18.
- obstruction 152 may be sma ller than the second inner diameter 1D 2 of the second obstruction engagement 144 and larger than the first inner diameter ID] of the first obstruction engagement 124, which may enable the first obstruction 152 to pass through the second obstruction engagement 144 and engage with ⁇ e.g., become lodged in) the first obstruction engagement 124,
- drilling fluid pressure against the first obstruction 152 may increase as flow out the lower end 128 of the travel sleeve 1 18 is at least partially impeded.
- the pressure exerted by the drilling fluid may be sufficient to disconnect the travel sleeve 18 from the housing 102.
- the pressure exerted by the drilling fluid may produce a shear stress within the detachable hardware 120A greater than a shear strength of the detachable hardware 120A (see FIG.
- the pressure exerted by the drilling fluid may then cause the travel sleeve 1 18 to move from the first sleeve position to a second, different sleeve position.
- the pressure may cause the travel sleeve 1 18 to move from a first, upper sleeve position to a second, lower sleeve position.
- Movement of the travel sleeve 1 1 8 may be arrested in the second sleeve position by reducing or re!ieving the pressure exerted by the drilling fluid, by abutting the lower end 128 of the travel sleeve 1 18 against the housing 102 (e.g., against a sleeve stop MSA of the housing 102), or both.
- a seal may not be formed between the travel sleeve 1 18 and the sleeve stop MSA to enable drilling fluid to still flow out the first ports 126, into the internal bore 104, and out of the housing 102.
- the lower end 128 of the travel sleeve 1 1 8, the sleeve stop 148A, or both may comprise a scalloped edge or a scalloped surface to create a space in which drilling fluid may flow.
- the trigger sleeve 136 may remain detachably connected to the travel sleeve 1 18 and move with the travel sleeve 1 18 as the travel sleeve 1 18 moves to the second sleeve position.
- the first ports 126 of the travel sieeve 1 18 may move from a first side of the sealing members 132 to a second, opposing side of the sealing members 132.
- the first ports 126 may move from a first side above the sealing members 132 (see FIG. 2) to a second side below the sealing members 132.
- Drilling fluid may then escape from the internal flow path 122 of the travel sleeve 1 38, through the first ports 126, to the internal bore 104 of the housing 02, and out the lower end 1 10 of the housing to at least partially relieve the pressure exerted by the drilling fluid against the first obstruction 152.
- Movement of the travel sleeve 1 1 8 from the first sleeve position to the second sleeve position may release the locking dogs 50, which previously retained the blades 1 14 in the retracted position.
- the locking dogs 150 may bear against the travel sleeve 1 18 and a push sleeve 154 connected to the blades 1 14 when the travel sleeve 1 18 is in the first sleeve position.
- Movement of the travel sleeve 1 18 to the second sleeve position may cause the Socking dogs to cease bearing against the travel sleeve 1 18 and the push sleeve 154. which may enable the push sleeve 154 to move the blades 1 14 to the extended position.
- drilling fluid flowing in the internal bore 104 of the housing 102 may exert a pressure against the push sieeve 154 to move the push sleeve 154, which may cause the blades 1 14 to move correspondingly to the extended position.
- the blades 1 14 may engage a wall of the borehole to remove formation material and enlarge the borehole diameter as the expandable reamer 100 rotates in the borehole.
- the blades 1 14 may be biased toward the retracted position.
- a biasing member 156 e.g., a spring
- the pressure of the drilling fluid may be sufficient to overcome the bias of the blades 1 14 toward the retracted position to move the blades 114 to the extended position.
- the pressure exerted by the drilling fluid may produce a force exerted against the push sleeve 154 greater than a force exerted by the biasing member 156 against the push sleeve 154.
- the pressure exerted by the drilling fluid against the push sleeve 154 may move the push sleeve 154, overcome the bias of the biasing member 156 (e.g., by compressing the biasing member 156), and cause the blades 1 14 to move to the extended position.
- Increasing or decreasing the pressure exerted by the drilling fluid may cause the blades 1 14 to move selectively between the extended position and the retracted position while the expandable reamer 100 is in the second operational state.
- the pressure exerted by the drilling fluid may be reduced below the pressure exerted by the biasing member 156, which may cause the biasing member 156 to expand and bear against the push sleeve 154.
- the push sleeve 154 may move in response to the expansion of the biasing member 156, and the blades 1 14 may be returned to the retracted position.
- the pressure exerted by the drilling fluid may be increased above the pressure exerted by the biasing
- the blades 1 14 may be movable between the extended position and the retracted position, the travel sleeve 1 18 may be in the second sleeve position, and the trigger sleeve 136 may be in the unobstructed position when the expandable reamer 100 is in the second operational state.
- a cross-sectional view of the expandable reamer 100 of FIG. 1 is shown in a third operational state (e.g., a third mode of operation).
- a third operational state may correspond to a de-activated, final, retracted state, and may reflect a state of the expandable reamer 100 after reaming the borehole is complete and during removal of the expandable reamer 100 from the borehole.
- the actuation mechanism of the expandable reamer 100 may be deactivated to return the blades 1 14 to their retracted positions and to significantly reduce the likelihood that that blades 1 14 will move to the extended position responsive to increases in drilling fluid pressure (e.g., to prevent the blades 1 14 from moving to the extended position responsive to increases in drilling fluid pressure).
- a second obstruction 158 may be released into the interna! bore 104 to engage with the second obstruction engagement 144 of the trigger sleeve 136.
- the second obstruction 158 may comprise, for example, a ball, a sphere, an ovoid, or other three-dimensional shape that may be released into the internal bore 104 to engage with the second obstruction engagement 144 and at least partially impede flow of drilling fluid out the lower end 146 of the trigger sleeve 136.
- a second outer diameter OD of the second obstruction 158 may be larger than the second inner diameter ID 2 of the second obstruction engagement 144, which may cause the second obstruction 158 to engage with (e.g., become lodged in) the second obstruction engagement 144.
- drilling fluid pressure against the second obstruction 158 may increase as flow out the lower end 146 of the trigger sleeve 136 is at least partially impeded.
- the pressure exerted by the drilling fluid may be sufficient to disconnect the trigger sleeve 136 from the travel sleeve 1 18.
- the pressure exerted by the drilling fluid may produce a shear stress within the detachable hardware 120B greater than a shear strength of the detachable hardware 120B (see FIGS, 2 and 3) to shear the detachable hardware ⁇ 20 ⁇ in embodiments where the detachable hardware 120B comprises shear pins or shear screws.
- the pressure exerted by the drilling fluid may then cause the trigger sleeve 136 to move from the unobstructed position to an obstructed position.
- the pressure may cause the trigger sleeve 136 to move from an unobstructed position in which the trigger ports 142 are at least substantially aligned with the second ports 130 of the travel sleeve 118 to an obstructed position in which the sidewall 138 obstructs the second ports 130.
- Movement of the trigger sleeve 136 may be arrested in the obstructed position by reducing or relieving ihe pressure exerted by the drilling fluid, by abutting the lower end 146 of the trigger sleeve 136 against the travel sleeve 3 38 (e.g., against a sleeve stop 148B of the travel sleeve 1 18), or both.
- a seal may not be formed between the trigger sleeve 136 and the sleeve stop 148B to enable drilling fluid to still flow out the trigger ports 142 and the first ports 126, into the internal bore 104, and out of the housing 102.
- the lower end 146 of the trigger sleeve 136, the sleeve stop 148B, or both may comprise a scalloped edge or a scalloped surface to create a space in which drilling fluid may flow.
- the trigger ports 142 of the trigger sleeve 136 may move from the first side of the sealing members 132 to the second, opposing side of the sealing members 132.
- the trigger ports 342 may move from a first side above the sealing members 132 (see FIGS. 2 and 3) to a second side below the sealing members 1 32, which may cause the trigger ports 142 to at least substantially align with the first ports 126 of the travel sleeve 1 18.
- Movement of the trigger ports 142 out of at least substantial alignment with the second ports 130 of the travel sleeve 1 18 may cause the sidewall 138 of the trigger sleeve 136 to obstruct the second ports 130 (as shown in dashed lines). Drilling fluid may then escape from the internal flow bore 140, through the trigger ports 142 and the first ports 326, to the internal bore 104 of the housing 102, and out the lower end 1 10 of the housing to at least partially relieve the pressure exerted by the drilling fluid against the second obstruction 158.
- drilling fluid may be redirected from flowing through the second ports 130, to the internal flow bore 140, through the trigger ports 1 2 and the first ports 126, to the internal bore 104 of the housing 102, and out the lower end 1 10 of the housing to at least partially relieve the pressure exerted by the drilling fluid against the push sleeve 154.
- the second obstruction 158 may remain engaged with the second obstruction engagement 144 during and after movement of the trigger sleeve 136 because at least substantial alignment between the trigger ports 142 and the first ports 126 may enable drilling fluid to be redirected around the second obstruction 158.
- drilling fluid may be expelled from the internal bore 104, through a relief valve 160, and out to an exterior of the expandable reamer 100 to at least partially relieve the pressure exerted by the drilling fluid against the push sleeve 554,
- Reduction in the pressure exerted by the drilling fluid against the push sleeve 154 may cause the blades to return to the retracted position.
- the pressure of the drilling fluid may be less than a pressure exerted by the biasing member i 56 against the push sleeve 154.
- the pressure exerted by the biasing member 156 against the push sleeve 154 may move the push sleeve 154 (e.g., by expanding the biasing member 156), overcome the pressure exerted by the drilling fluid, and cause the blades 1 14 to move to the retracted position.
- the return of the blades 114 to the retracted position may last for at least as long as the expandable reamer 100 remains in the borehole.
- obstruction of the second ports 130 by the sidewalS 138 of the trigger sleeve 136 may significantly reduce (e.g., eliminate) the likelihood that increases in pressure exerted by the drilling fluid will be sufficient to overcome the bias of the biasing member 156 and move the blades to the extended position.
- the blades 1 14 may remain in the retracted position regardless of increases or decreases in pressure exerted by the drilling fluid because of the redirection of flow from the push sleeve 154.
- the blades 1 14 may be in the retracted position, the travel sleeve 18 may be in the second sleeve position, and the trigger sleeve 136 may be in the obstructed position when the expandable reamer 100 is in the third operational state.
Abstract
Description
Claims
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
NO20141206A NO346877B1 (en) | 2012-04-03 | 2013-04-03 | Expandable expansion drills and methods of using expandable expansion drills |
GB1419581.2A GB2518536B (en) | 2012-04-03 | 2013-04-03 | Expandable reamers and methods of using expandable reamers |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
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US201261619869P | 2012-04-03 | 2012-04-03 | |
US61/619,869 | 2012-04-03 |
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WO2013152099A1 true WO2013152099A1 (en) | 2013-10-10 |
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Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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PCT/US2013/035112 WO2013152099A1 (en) | 2012-04-03 | 2013-04-03 | Expandable reamers and methods of using expandable reamers |
Country Status (4)
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US (2) | US9267331B2 (en) |
GB (1) | GB2518536B (en) |
NO (1) | NO346877B1 (en) |
WO (1) | WO2013152099A1 (en) |
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US8960333B2 (en) | 2011-12-15 | 2015-02-24 | Baker Hughes Incorporated | Selectively actuating expandable reamers and related methods |
US9267331B2 (en) * | 2011-12-15 | 2016-02-23 | Baker Hughes Incorporated | Expandable reamers and methods of using expandable reamers |
WO2015114407A1 (en) * | 2014-01-31 | 2015-08-06 | Tercel Ip Limited | Downhole tool and method for operating such a downhole tool |
US10557326B2 (en) | 2017-12-01 | 2020-02-11 | Saudi Arabian Oil Company | Systems and methods for stuck pipe mitigation |
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GB2518536B (en) | 2019-06-12 |
US20160153242A1 (en) | 2016-06-02 |
GB201419581D0 (en) | 2014-12-17 |
NO346877B1 (en) | 2023-02-06 |
US9719305B2 (en) | 2017-08-01 |
NO20141206A1 (en) | 2014-10-20 |
GB2518536A (en) | 2015-03-25 |
US20130256035A1 (en) | 2013-10-03 |
US9267331B2 (en) | 2016-02-23 |
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